Method and apparatus for cementing casing sections in well bores

ABSTRACT

Casing sections are cemented in a well bore between producing zones in an upward sequence starting from the bottom. Each casing section is lowered on a running string and running tool to its setting point, the casing section then being rotated to expand cutter supporting members carried by the casing outwardly to cut a formation shoulder for supporting the cutter members and casing. The running tool is released from the casing and lowered therewithin to the casing float shoe, cement being pumped through the running string, tool and shoe to cement the casing in place, the running string and tool being removed from the hole.

United States Patent 1 [72] Inventors Archer W. Kammerer,Jr.

Fullerton; Gary R. Johnson, Anaheim, Calif.

[21] Appl. No. 765,474

[22] Filed Oct. 7, 1968 [45] Patented Mar. 16, 1971 [73] Assignee RotaryOil Tool Company Buena Park, Calif.

[54] METHOD AND APPARATUS FOR CEMENTING CASING SECTIONS IN WELL BORES 35Claims, 11 Drawing Figs.

52 U.S. c1. 166/290, 166/315, 166/208, 166/243 51 Int.Cl ..1:21b33/14,E21b23/OO s01 Field'ofSearch 166/290, 4 315, 212, 242, 243; 166/206,207, 20s

[56] ReferencesCited UNITED STATES PATENTS 1,233,888 7/1917 Leonard166/207x Primary ExaminerDavid H. Brown Attorney-Bernard KriegelABSTRACT: Casing sections are cemented in a well bore between producingzones in an upward sequence starting from the bottom. Each casingsection is lowered on a running string and running tool to its settingpoint, the casing section then being rotated to'expand cutter supportingmembers carried by the casing outwardly to cut a formation shoulder forsupporting the cutter members and casing. The running tool is releasedfrom the casing and lowered therewithin to the casing float shoe, cementbeing pumped through the running string, tool and shoe to cement thecasing in place, the running string and tool being removed from thehole.

PATENTEUHARIBIB?! 3570.603

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Gnes 12 claw/so METHGD AND APFTEJS FGR CEW SECTIONS m WELL BGRES Thepresent invention relates to subsurface well bore apparatus, and moreparticularly to the running-in, supporting and cementing of casing inwell bores.

Where a plurality of producing zones are present in a well bore, astring of casing is lowered in the well bore and the easing cemented inplace to seal off the water sand zones between the producing zones. Thecasing may be perforated at each producing zone, or it may be milledaway at each producing zone, the hole then being enlarged through use ofa suitable expandable type of hole opener to remove the cement andexpose the producing formation. It has also been proposed heretofore forthe water sand zones themselves to be cemented off, leaving theproducing zones free from cementitious materials. In such situations,the casing is either initially in a perforate condition between eachproducing zone, the perforations being opened at the appropriate time,or the casing sections at the producing zones are perforated or milledaway, a suitable hole opening tool with expandable cutters being run inthe well for the purpose of enlarging the hole diameter, so as tofacilitate flow of the production into the easmg.

The running of a solid string of casing in the well bore, followed bythe different types of cementing operations referred to above, is acostly and time-consuming operation, particularly in well bores having asubstantial number of separate producing zones, which, for example, maybe many as five in number. The present invention greatly reduces thecost of securing a cement bond between casing sections at the water sandzones and the securing of the producing zones in an opened condition forthe freedom of flow of the production into the well bore.

In the present invention, an appropriate length of casing is lowered ona running string into the well bore and is located between producingzones. A shoulder is formed in the formation by expanding cuttersoutwardly against the formation, the cutters being supported by theshoulder so that the running string of pipe need no longer support thecasing. In hard formations, the shoulder may be cut prior to loweringthe casing in the well bore. The cutters or like supporting members arelocked in their outwardly expanded conditions, resting upon theformation shoulder, and will remain in such conditions despite therelease of a running tool from the length of casing, which will permitthe running tool to be used in cementing the casing sections in place,which is done by pumping cement down through a drill pipe, or othertubular string, extending to the drilling rig and from the lower portionof the well casing for upward passage along the casing string, toprovide an annular body of cement securing the casing in the well boreand cementing off the water and other zones in the well bore between theproducing zones. The running string of drill pipe and the running toolassociated therewith are then removed from the casing and elevated tothe top of the well bore.

The foregoing sequence of operations is then repeated with other desiredlengths of casing in an upward sequence, each casing being lowered toits appropriate location between adjacent producing zones, anchored inplace by the act of causing its expanding cutters to produce a shoulderin the formation to support the casing string, the casing then beingcemented in place and the running tool then being removed from the wellbore.

After all of the lengths or sections of casing are cemented in place,and the running tool removed from the well bore, a bit is secured to thedrill pipe and run in the well bore to drill out all of the internaldevices in the casing string. The bit is then removed and a suitablehole opener lowered on the drill pipe into the well bore, for-thepurpose of enlarging the well bore .at each producing zone betweencasing sections.

This invention possesses many other advantages and has other purposeswhich may be made more clearly apparent from a consideration of a formand method embodying the invention. This form and method are shown anddescribed in the present specification and in the drawings accompanyingand f CASHNG constituting a part thereof. They will now be described indetail, for the purpose of illustrating the general principles of theinvention; but it is to be understood that such detailed FIG. 3 is aview similar to FIG. 2 illustrating the fonnation shoulder having beencut and the apparatus in condition for supporting the casing weight fromthe formation shoulder;

FIG. 4 is a view similar to FIG. 3 illustrating the apparatus in anothercondition with circulation ports open, the apparatus in condition forlocking the expandable cutters in their ex-' panded condition;

FIG. 5 is a view similar to FIG. 2, 3 and 4 illustrating the runningtool released from the well casing and the cutterblades or anchormembers positively locked in their expanded condition;

FIG. 6 is a quarter longitudinal sectional view illustrating the runningtool within the casing and the cementing of the casing in the well bore;

FIG. 7 is a view similar to FIG. 6 illustrating upper circulation portsopen for the purpose of flushing the excess cement from the interior ofthe well casing and drill pipe;

FIG. 8 is a longitudinal section similar to FIGS. 2 to 7, inclusive,illustrating the running tool completely removed from the well casing inthe well bore;

FIG. 9 is a cross section taken along the line 9-9 on FIG. 2; H6. 10 isa cross section taken along the line 10-10 on FIG. 3; and

FIG. 11 is a cross section taken along the line 11-11 on FIG. 4.

The drawings illustrate an apparatus and a method for cementing separatelengths or sections of casing A, B, C in a well bore D between producingzones E, F, G. FIG. 3; illustrates a plurality of casing sectionscemented in place; whereas, the other FIGS. illustrate a single lengthof casing and associated apparatus, which is to be cemented in the wellbore between producing zones at each end thereof.

As shown more particularly in FIGS. 2 to 11, inclusive, a suitablelength of easing, such as the'casing A, which, for example, may be from2 to 500 feet in length, depending upon the distance between producingzones E, F, has its lower end constituted as a bull plug casing shoe Hof any known type. As specifically illustrated, the casing shoe isthreadedly secured to the lower end of an adjacent casing section A andhas a downwardly facing valve seat 10 therein adapted to prevent returnflow of cement slurry, or other fluids, when engaged by a suitable ballcheck valve member ll therebelow, the downward movement of the ball fromits seat being limited by engagement with suitable circumferentiallyspaced fingers 12 attached to the body 13 of the casing shoe. Thecentral passage is through the casing shoe is closed by a suitable plug15 threaded to the body, so that fluid flowing downwardly through thevalve seat ll) will pass outwardly through side ports 16 in the casingshoe into the annulus .l surrounding the well casing. Since it isdesired that the cement be prevented from flowing downwardly of theshoe, a suitable basket 17 is provided, which may be of the typespecifically illustrated in U.S. Pat. No. 2,117,538. This basket mayconsist of circumferentially spaced longitudinal springs 18, the lowerportions of which are suitably secured to the body l3 of the casingshoe, the spring arms and associated overlapping leaf spring members 19diverging in an upward direction and being" adapted to engage and slideupon the wall of the well borefl Thus, the cement slurry is confined formovement upwardly from the basket 17 along the length of the casingstring A.

The upper end of the casing A is nonrotationally securedto' a supportingand anchor device 20, which is capable of wil porting the entire lengthof casing and the column of cement deposited therearound in the annulusJ. This device includes a tubular body 21, the lower end of which isconnected to the upper portion of the casing string A by a suitableswivel 22, permitting the body to rotate without rotating the casing.The swivel may take any suitable form. As illustrated, it consists of aplurality of balls 23 located in opposed raceways 24, 25 in the casingand body, respectively, the balls being inserted in place between theraceways 24, 25 through a suitable radial hole 26 in the body closed bythe threaded plug 27.

The body 21 carries a plurality of anchor or supporting cutter blades 28disposed in longitudinally extending body slots 29. Each blade ispivotally mounted on a hinge pin 30 extending through the blade acrossits associated slot and suitably secured to the body, the bladedepending from its hinge pin and having a rearward foot portion 31extending from the trailing side of the blade to increase the lowerwidth or effective thickness of the blade (FIG. The upper portion ofeach slot 29 above the foot portion has a width slightly greater thanthe thickness of the main portion of the anchor blade 28, the lowerportion of the slot being wider to accommodate the foot portion 31 andpermit its passage in a lateral outward direction through the slot.

The blades initially occupy an inward or retracted position, asdisclosed in H6. 2, in which their outer longitudinal sides 32 aredisposed substantially entirely within the confines of the body 21. Itsinner portion 33'then inclines in an inward and downward direction. Suchinward portion includes a tapered or expander portion 34 and also a stopflange 35 extending transversely outwardly of the leading face of theblade, the arrangement being such that outward expansion of each bladeis limited by engagement of the flange 35 with the inner wall of thebody at one side of the body slot 29, such as illustrated most clearlyin MG. 10.

When in their retracted position, the inner portions of the bladesextend through slots 48 of a tubular mandrel 37 disposed within the body21. Downward movement of the mandrel relative to the body is preventedinitially by a plurality of segments 38 extending through tapered sideopenings 39 in the body and extending into a counterbore 40 in the bodyin engagement with an upwardly facing, tapered body shoulder 41 providedby the counterbore. The shoulder 41 and lower side of the segments 38taper in an inward and outward direction. The segments are held in theiroutward position by a holding and expander sleeve 42 within the mandrel37, this sleeve being held in an initial upward position within themandrel by a plurality of shear screws 43. When in such upwardcondition, the sleeve retains the thrust segments 3% within thecounterbore 40, which precludes downward movement of the mandrel 37within the body 21. Upward movement of the mandrel with respect to thebody is then prevented by an inherently expandable split lockring 44disposed in an external circumferential groove 45 in the mandrel, withits upper side engaging a downwardly facing shoulder 46 in the body.

Lateral extending expander lugs 47 are integral with the lower portionof the sleeve 42, such lugs extending through longitudinal slots 48 inthe lower portion of the mandrel 37, and being initially disposed abovethe major portion of the anchor blades 28, the inner portions of theblades extending through the mandrel slots 48 with the expander bladeportions disposed below the sleeve lugs 47, as illustrated in FIG. 2.The upper portions of the mandrel slots are slightly wider than thethickness across the blade and stop flange 35, the rotational drive, asexplained hereinbelow, being transmitted from the mandrel 37 through thetrailing side of each of its slots to the trailing face of an associatedblade 28. With the blades in the retracted position, a lock sleeve 49 isdisposed in its upper position within the body, as disclosed in H6. 2.

When the sleeve 42 is shifted downwardly within the mandrel, as a resultof shearing the upper screws 43, the lugs 47 engage the tapered expanderportions 34 of the anchor blades I and expand them outwardly. Duringtheir outward expansion, the string of drill pipe P to which the mandrelis secured and the mandrel are being rotated, the torque of the mandrelbeing transmitted directly to the anchor blades 23, the lower corner 50of which will engage the formation and portion cutting it away. At thistime, the drill pipe string and mandrel are maintained in the samevertical position, the anchor blades 28 swinging outwardly andpenetrating into the formation as the body 31 and blades are rotated,until the blades have been expanded fully outwardly, as illustrated inFIG. 3, to produce an upwardly facing formation shoulder R engaged bythe lower ends 51 of the blades and their foot portions 31. At thistime, the sleeve 42 will have shifted downwardly to the extent at whichits upper flange 52 engages alower set of shear screws 53 disposed belowthe upper shear screws 43 by a predetermined distance, these shearscrews 53 being received within an elongate circumferential groove 54 inthe upper portion of the sleeve. The lugs 47 on the expander sleeve 42will have shifted downwardly off the tapered expander surfaces 34 of theblades when the upper sleeve flange 52 engages the lower set of shearscrews 53, the inner surfaces 33 of the fully expanded blades thenhaving an effective internal diameter which is no smaller than theexternal diameter of the mandrel Downward shifting of the sleeve 42within the mandrel 37 occurs hydraulically. When the setting location ofthe casing string A has been reached, a trip ball 54 is dropped orpumped down the drill pipe, the ball passing through a sleeve valvemember 55 of a circulation valve 56 formed in the upper portion of themandrel 37, and covering side circulation ports 57, the sleeve valvemember being held in its port closing position initially by one or aplurality of shear screws 58 releasably securing it to the mandrel. Thissleeve valve member 55 has suitable seal rings 59 thereon engaging themandrel on opposite sides of the circulation ports 57. The trip ball isof a smaller diameter than the passage through the sleeve 55, so that itcan pass downwardly therethrough and through the central passage 60 ofthe piston sleeve member into engagement with a ball seat 61 in itslower portion. When the ball 54 engages the seat 61, the upper shearscrews 43 are still intact, and the parts are in the positionillustrated in FIG. 2. At this time, side ports 62 in the sleeve valve42 are closed by being disposed within an imperforate intermediateportion 63 of the mandrel, seal rings 64 being provided on the sleeve onopposite sides of its ports 62 for sealing engagement with the wall ofthe mandrel.

When the trip ball 54 engages its seat 61, pressure can be built up inthe tubular string of drill pipe P and within the mandrel 37, for thepurpose of shearing the upper screws 33 and effecting expansion of theanchor blades 23 while the drill pipe and mandrel are being rotated torotate the anchor blades and the entire body 21 around the formation,such rotation occurring without corresponding rotation of the casingstring A because of the provision of the swivel 22. When the blades havebeen fully expanded, as disclosed in FIG. 3, and with the upper sleeveflange 52 engaging the lower set of shear screws 53, the sleeve ports 62are still in the closed condition.

The efficacy of the formation shoulder R and blades 28 in supporting thecasing A is then tested by setting down a desirable amount of weight onthe drilling string P, which is trans mitted through the segments 38 tothe body 21 of the tool and through the anchor blades 28 to theformation shoulder R. If the formation shoulder holds the down weightimposed upon it, as well as the weight of the casing section Atherebelow, the fluid pressure in the drill pipe and the setting tool isincreased to cause the sleeve 42 to shear the lower set of screws 53,the

sleeve moving downwardly to its lowermost position within the mandrel37, in which the ports 62 are disposed in alignment with the mandrelslots 42, the elongate circumferential groove 54 of the sleeve thenbeing disposed in alignment with or behind the segments 3b, asillustrated in FlG. 4. The fact that the parts are in this relativeposition will be indicated to the operator at the top of the well boreby the open condition of the ports 62 and the ability to circulate fluiddown through the tubing string 1?, and out through the ports 62 andmandrel slots 48 into the casing A therebelow, the circulation fluidpassing through the shoe H and out through the ports id for upwardpassage in the well bore around the casing section A.

Since the casing is now being supported by the blades or supportingmembers 28 resting upon the formation shoulder R, the drill pipe P andmandrel 37 are then lowered. The segments 38 engage the tapered shoulder41 on the body 21 and are shifted inwardly completely out of the bodyand within the confines of the mandrel, freeing the mandrel for movementdownwardly within the body. Such downward movement carries the splitlockring 44 downwardly with it, this ring being in engagement with theupper end of the lock sleeve 49 and shifting the latter downwardlybehind the upper portion of the expanded blades 28. Just prior toengagement of the lock sleeve with the expander portions 34 of theblades, the inherently expansible lockring 44 becomes positionedopposite an internal circumferential groove 70 in the body 21, thelockring expanding into such groove and completely out of the externalmandrel groove 45. The mandrel is thereby freed from the upper body 21and casing A and is movable downwardly within the casing A, with thelock sleeve 49 retaining the blades 28 in their outward expandedcondition, as illustrated in FIG. 5.

The mandrel 37 carries a downwardly facing packing cup 71 of elastomermaterial and having a diameter conforming to the inside diameter of thecasing string A, this cup being suitably fixed to the mandrel below itscirculation ports 57 and being capable of sliding downwardly through thebody 21, lockring 49, expanded blades 28 and along the wall of thecasing therebelow. The drill pipe P and mandrel 37 are then lowered inthe casing until the mandrel is disposed immediately above the casingshoe H (FIG. 6). Circulation fluid can then be pumped down through thedrill pipe P and through the mandrel 37, discharging through the sleeveports 62 and passing through the mandrel slots 48 into the casing A, andthen through the valve seat 10 and out through the ports 16 into thebasket 17, then flowing upwardly through the annulus surrounding thewell casing. This circulation fluid is followed by a suitable charge ofcement slurry pumped down through the drill pipe and through theapparatus, discharging through the shoe ports 16 and passing upwardlyaround the casing to the anchor blades 28 and body 21, the slurry beingappropriately calculated in volume so as to avoid its being depositedalong the formation zone above the upper end of the flaring mouth 75 ofthe body 21, as well as to avoid its spilling into the casing throughsuch mouth. A ball or suitable plug element 76 may be placed in thedrill pipe at the upper end of the charge of cement slurry, this ballcoming to rest upon the valve sleeve of the circulation valve 56,whereupon further ejection of cement from the well casing will cease. Anincrease in fluid pressure in the drill pipe string will cause the shearscrews 58 to be disrupted and the sleeve valve 55 to shift downwardlyinto engagement with a mandrel shoulder 80, opening the circulationports 57 and allowing any excess cement in the well bore or in thecasing string itself to be flushed from the well bore. As illustrated inFIG. 7, washing or circulating fluid can be pumped downwardly into theannulus S between the drill pipe string P and the wall of the well bore,such fluid, as well as the fluids in advance of it in the well bore,passing through the circulation ports 57 to the interior of the stringof drill pipe, flowing upwardly therethrough to the drilling rig. Thecement slurry deposited behind the casing cannot move downwardly throughthe shoe ports 16, in view of the upward seating of the ball check valveelement ll of the casing shoe.

After reverse circulation or, if desired, circulation down through thedrill pipe P and upwardly therearound has been completed, the drill pipestring P and the running tool 37, 42 are pulled from the well casing Aand the well bore D to the drilling rig, leaving the casing with cementdeposits behind it and in the condition illustrated in FIG. 3, the borethrough the casing A and the body 21 thereabove being unobstructed,except for the presence of the internal mechanism of the casing shoe H,which is made of readily drillable material, as set forth in US. Pat.No. 1,994,850.

The next desired length of casing B an then be made up with its shoe Hand basket 17 at its lower end and attached to the body 21 and mandrel37 with the expander piston sleeve 42 and the circulation sleeve 55 inplace and in the positions illustrated in FIG. 2. This organization isrun in the well bore until the casing is located between a lowerformation zone F and an upper formation zone G thereabove, and theforegoing sequence of forming a formation shoulder R to support thecasing B, testing the supporting ability of the blades 28 and theformation shoulder, releasing the mandrel 37 from the body 21, lockingthe blades outwardly, cementing the casing B in place, and removing thesetting tool and drill pipe being repeated. In the same fashion, othercasing sections, C etc. are lowered and cemented in place in upwardsequence between producing zones, until all of the casing sections arecemented in place, such as illustrated diagrammatically in FIG. 1.

After all the casing sections A, B, C, etc. have been cemented in place,and the drill pipe P and running tool 37, 42 removed, a suitable sizedrill bit (not shown) is secured to the string of drill pipe and islowered in the well bore D, the drill pipe being rotated to drill outthe internal mechanisms of all the shoes and other obstructions thatmight have been incorporated in the casing strings. When this operationhas been completed, the drill pipe and bit are removed from the wellbore. A hole opener (not shown) having expandable cutters, which, forexample, may be of the type illustrated in U.S. Pat. No. 2,758,819 isthen secured to the drill pipe P and lowered in the well bore, itscutters expanded outwardly at each producing zone to enlarge the wellbore at each of the producing zones between casing sections. Suitablewell completion equipment can now be run in and set in the casingsections, such as well packers and the like.

It is, accordingly, apparent that a method and an apparatus forperforming the method have been provided, which will appropriatelysupport each length or section of casing between producing zones whilethe cementing operation is being conducted and without cementing thewell bore along the producing zones E, F, G, etc. Thus, water bearingsand zones and the like may be sealed off and the producing zonesisolated from one another in a known manner by use of other equipment(not shown). It is unnecessary to effect any perforation of casing, rununneeded casing along the producing zones, and effeet a milling away ofthe casing sections if it is desired to expose one or more of theproducing zones.

We claim:

1. A method of supporting a casing section in a well bore and carryinginitially retracted supporting members, comprising lowering the casingsection in the well bore to a desired setting point, forming asupporting formation shoulder in the formation wall of the well bore,expanding the supporting members after lowering the casing section tothe desired setting point, and resting the supporting members on thesupporting formation shoulder to support the weight of the casingsection.

2. A method of supporting a casing section in a well bore and carryingsupporting members, comprising lowering the casing section in the wellbore to a desired setting point, forming a supporting shoulder in theformation wall of the well bore, and resting the supporting members onthe supporting shoulder; wherein the supporting members are laterallyexpandable, forming the supporting shoulder by rotating at least aportion of said casing section while laterally expanding the supportingmembers to cause the supporting members to cut into the formation wall.

3. A method as defined in claim 2; a hydraulic force being imposed onthe supporting members while said portion of the casing section is beingrotated to laterally expand the supporting members to cause firesupporting members to out into the formation wall and produce thesupporting shoulder on which the supporting members rest.

4. A method of supporting a casing section in a well bore and carryingsupporting members, comprising lowering the casing section in the wellbore to a desired setting point, forming a supporting shoulder in theformation wall of the well bore, and resting the supporting members onthe supporting shoulder; the casing section comprising an upperrotatable portion swivelly connected to a lower casing portion, thesupporting members being laterally expandable and carried by the upperrotatable portion, forming the supporting shoulder by rotating the upperrotatable portion and cutters by laterally expanding the supportingmembers to cause the supporting members to cut into the formation wall.

5. A method of supporting and cementing a casing section in a well bore,the casing section carrying supporting members, comprising releasablyconnecting the casing section to a running tool and lowering the casingsection and running tool in the well bore on a tubular string to adesired setting point, forming a supporting shoulder in the formationwall of the well bore, resting the supporting shoulder in the formationwall of the well bore, resting the supporting members on the supportingshoulder, cementing the casing section in the well bore while thesupporting members rest on the shoulder, and releasing the running toolfrom the casing section for withdrawal of the running tool from the wellbore.

6 A method as defined in claim wherein the running tool is released fromthe casing section prior to cementing the casing section in the wellbore, lowering the running tool in the casing section to the lowerportion of the casing section, then pumping cementitious materialthrough the tubular string and running tool into the casing section fordischarge from the casing section and upward flow around the casingsection.

7. A method as defined in claim 5; wherein the supporting members arelaterally expandable, forming the supporting shoulder by rotating thetubular string, running tool, and at least a portion of said casingsection while laterally expanding the supporting members to cause thesupporting members to cut into the formation wall and produce thesupporting shoulder on which the supporting members rest.

8. A method as defined in claim 5; the casing section comprising anupper rotatable portion swivelly connected to a lower casing portion,the supporting members being laterally expandable and carried by theupper rotatable portion, the running tool being releasably connected tothe upper rotatable portion, forming the supporting shoulder by rotatingthe tubular string, running tool, upper rotatable portion, andsupporting members carried thereby while exerting a hydraulicallyimposed force on the supporting members to laterally expand thesupporting members to cause the supporting members to cut into theformation wall and produce the supporting shoulder on which thesupporting members rest.

9. A method as defined in claim 5; the casing section comprising anupper rotatable portion swivelly connected to a lower casing portion,the supporting members being laterally expandable and carried by theupper rotatable portion, the running tool being releasably connected tothe upper rotatable portion, forming the supporting shoulder by rotatingthe tubular string, running tool, upper rotatable portion, andsupporting members carried thereby while exerting a hydraulicallyimposed force on the supporting members to laterally expand thesupporting members to cause the supporting members to cut into theformation wall and produce the supporting shoulder on which thesupporting members rest, the running tool being released from the upperrotatable portion prior to cementing the casing section in the wellbore, lowering the running tool in the casing section to the lowerportion of the casing section, then pumping cementitious materialthrough the tubular string and running tool into the casing section fordischarge from the casing section and upward flow around the casingsection.

iii. in apparatus for supporting a casing section in a well bore: a bodyadapted to form part. of the casing section; laterally expandablesupporting members carried by the body; and means shiftablelongitudinally of said body for expanding said members laterallyoutwardly to penetrate said members into the formatio'n wall of the wellbore or to rest said members on a formation shoulder, whereby saidmembers support the weight of said body in the casing section from theformation wall or formation shoulder.

1111. in apparatus as defined in claim 10; and means for locking saidmembers in their outwardly expanded position.

12. In apparatus for supporting a casing section in a well bore: a bodyadapted to form part of the casing section; laterally expandablesupporting members carried by the body; and means for expanding saidmembers laterally outwardly to penetrate said members into the formationwall of the well bore or to rest said members on a formation shoulder,whereby said members support the weight of said body in the casingsection from the formation wall or formation shoulder; said body havingswivel means for connecting said body to the portion of the casingsection therebelow.

13. in apparatus for supporting a casing section in a well bore: a bodyadapted to form part of the casing section; laterally expandablesupporting members carried by the body; and means for expanding saidmembers laterally outwardly to penetrate said members into the formationwall of the well bore or to rest said members on a formation shoulder,whereby said members support the weight of said body in the casingsection form the formation wall or formation shoulder; a running tooladapted to be secured to a running string and releasably connected tosaid body for lowering the body and remainder of the casing section inthe well bore; and means drivably connecting said running tool to saidsupporting members whereby rotation of said running tool rotates saidsupporting members while they are being expanded laterally outwardly toproduce the formation shoulder on which said supporting members canrest.

M. In apparatus as defined in claim 13; said body having swivel meansfor connecting said body to the portion of the casing sectiontherebelow.

15. In apparatus as defined in claim '13; said expanding meanscomprising a member slidable downwardly in said running tool inengagement with said supporting members to expand said members laterallyoutwardly.

16. in apparatus as defined in claim 13; said expanding means comprisinga fluid-actuated member slidably longitudinally in said running tool andmovable downwardly by fluid pressure in the running string in engagementwith said supporting members to expand said members laterally outwardly.

17. In apparatus as defined in claim 13; said drivable connected meansincluding slots in said running tool into which said supporting membersextend when in retracted position and during their lateral outwardexpansion.

18. in apparatus as defined in claim 13; and means for transmittingdownwardly directed thrust from said running tool to said body.

K9. in apparatus as defined in claim 13; means for transmittingdownwardly directed thrust from said running tool to said body; andmeans for releasing said thrust transmitting means from its transmittingrelation, permitting downward movement of said running tool in saidbody.

20. in apparatus as defined in claim 13; means for transmittingdownwardly directed thrust from said running tool to said body; meansfor releasing said thrust transmitting means from its transmittingrelation, permitting downward movement of said running tool in saidbody; and lock means shiftable downwardly by said running tool withinsaid body to a position behind expanded supporting members to lock saidmembers in their expanded condition.

l. in apparatus for supporting a casing section in a well bore: a bodyconnectable to the casing section to form a part thereof; laterallyexpandable supporting members carried by said body; a mandrel withinsaid body and 'connectable to a tubular running string; means fortransmitting rotary motion of said mandrel to members; an expanderslidable downwardly in said mandrel and engageable with said members toexpand said members laterally outwardly against the formation to producea shoulder in the formation during rotation of said mandrel and members;and means releasably connecting said mandrel to said body wherebyrelease of said connecting means permits said mandrel to movelongitudinally in said body to a position longitudinally removedtherefrom.

22. In apparatus as defined in claim 21; said motion transmitting meanscomprising slots in said mandrel receiving said members when saidmembers are in retracted position on said body and during lateralexpansion of said members.

23. in apparatus as defined in claim 21; said motion transmitting meanscomprising slots in said mandrel receiving said members when saidmembers are in retracted position on said body and during lateralexpansion of said members; said expander comprising means extending intosaid slots for engagement with said members.

24. 24. in apparatus as defined in claim 21; said expander comprising asleeve having a seat, and a trip member movable through the tubularstring into engagement with the seat to enable pressure to be built upin the tubular string to fluidly shift said sleeve downwardly in saidmandrel in engagement with said members to expand said members.

25. in apparatus as defined in claim 21; said expander comprising asleeve having a seat, and a trip member movable through the tubularstring into engagement with the seat to enable pressure to be built upin the tubular string to fluidly shift said sleeve downwardly in saidmandrel in engagement with said members to expand said members; saidsleeve having one or more ports closed by said mandrel when said sleeveis in an upper position in said mandrel, said one or more ports beingopened when said sleeve has been shifted downwardly in said mandrel.

26. in apparatus as defined in claim 21; said expander comprising asleeve having a seat, and a trip member movable through the tubularstring into engagement with the seat to enable pressure to be built upin the tubular string to fluidly shift said sleeve downwardly in saidmandrel in engagement with said members to expand said members; saidmotion transmitting means comprising slots in said mandrel receivingsaid members when said members are in retracted position on said bodyand during lateral expansion of said members; said sleeve extending intosaid slots in engagement with said members.

27. In apparatus as defined in claim 21; said expander comprising asleeve having a seat, and a trip member movable through the tubularstring into engagement with the seat to enable pressure to be built upin the tubular string to fluidly shift said sleeve downwardly in saidmandrel in engagement with said members to expand said members; saidmotion transmitting means comprising slots in said mandrel receivingsaid members when said members are in retracted position on said bodyand during lateral expansion of said members; said sleeve extending intosaid slots in engagement with said members; said sleeve having one ormore ports closed by said mandrel when said sleeve is in an upperposition in said mandrel, said one or more ports being opened when saidsleeve has been shifted downwardly in said mandrel.

2%. ln apparatus as defined in claim 21; and packing means on saidmandrel for slidably sealing with the casing section following releaseof said mandrel from said body and downward movement of said mandrelwithin the casing section.

29. in apparatus as defined in claim 2i; said releasable connectingmeans comprising segments on said mandrel engaging said body to transmitdownward thrust from said mandrel to said body and also comprising asplit ring on said mandrel engaging said body whereby the weight of saidbody and casing section therebelow are supported by said. mandrel, andmeans for releasing said segments and split ring to release said mandrelfrom said body and permit movement of said mandrel longitudinally withinand from said body.

fill. in apparatus as defined in claim 21; and lock means shiftablebehind said members to retain said members in expanded condition.

31. In apparatus as defined in claim 2i; said expander comprising asleeve having a seat, and a trip member movable through the tubularstring into engagement with the seat to enable pressure to be built upin the tubular string to fluidly shift said sleeve downwardly in saidmandrel in engagement with said members to expand said members; saidmotion transmitting means comprising slots in said mandrel receivingsaid members when said members are in retracted position on said bodyand during lateral expansion of said members; said sleeve extending intosaid slots in engagement with said members; said releasable connectingmeans comprising segments on said mandrel engaging said body to transmitdownward thrust from said mandrel to said body and also comprising asplit ring on said mandrel engaging said body whereby the weight of saidbody and casing section therebelow are supported by said mandrel, andmeans for releasing said segments and split ring to release said mandrelfrom said body and permit movement of said mandrel longitudinally withinand from said body.

32. in apparatus as defined in claim 21; said expander comprising asleeve having a seat, and a trip member movable through the tubularstring into engagement with the sea to enable pressure to be built up inthe tubular string to fluidly shift said sleeve downwardly in saidmandrel in engagement with said members to expand said members; saidmotion transmitting means comprising slots in said mandrel receivingsaid members when said members are in retracted position on said bodyand during lateral expansion of said members; said sleeve extending intosaid slots in engagement with said members; said releasable connectingmeans comprising segments on said mandrel engaging said body to transmitdownward thrust from said mandrel to said body and also comprising asplit ring on said mandrel engaging said body whereby the weight of saidbody and easing section therebelow are supported by said mandrel; saidsleeve engaging said segments to retain said segments in engagement withsaid body, said sleeve being released from said segments upon downwardmovement in said mandrel to permit disengagement of said segments fromsaid body, a lock sleeve in said body positioned for engagement by saidsplit ring and shifted downwardly in said body behind said members inresponse to downward movement of said mandrel and ring in said body tolock said mem' bers laterally outwardly, said split ring beingexpandable from said mandrel upon downward movement of said lock sleeveto release said mandrel from said body and permit its movementlongitudinally within and from said body.

33. In apparatus as defined in claim 2i; said expander comprising asleeve having a seat, and a trip member movable through the tubularstring into engagement with the seat to enable pressure to be built upin the tubular string to fluidly shift said sleeve downwardly in saidmandrel in engagement with said members to expand said members; saidmotion transmitting means comprising slots in said mandrel receivingsaid members when said members are in retracted position on said bodyand during lateral expansion of said members; said sleeve extending intosaid slots in engagement with said members; said releasable connectingmeans comprising segments on said mandrel engaging said body to transmitdownward thrust from said mandrel to said body and also comprising asplit ring on said mandrel engaging said body whereby the weight of saidbody and easing section therebelow are supported by said mandrel; saidsleeve engaging said segments to retain said segments in engagement withsaid body, said sleeve being released from said segments upon downwardmovement in said mandrel to permit disengagement of said segments fromsaid body, a lock sleeve in said body positioned for engagement by saidsplit ring and shifted downwardly in said body behind said members inresponse to downward movement of said mandrel and ring in said body tolock. said members laterally outwardly, said split ring being expandablefrom said mandrel upon downward movement of said lock sleeve to releasesaid mandrel from said body and permit its movement longitudinallywithin and from said body; and packing means on said mandrel forslidably sealing with the casing section following release of saidmandrel from said body and downward movement of said mandrel within thecasing section.

34. In apparatus as defined in claim 21; said expander comprising asleeve having a seat, and a trip member movable through the tubularstring into engagement with the seat to enable pressure to be built upin the tubular string to fluidly shift said sleeve downwardly in saidmandrel in engagement with said members to expand said members; saidmotion transmitting means comprising slots in said mandrel receivingsaid members when said members are in retracted position on said bodyand during lateral expansion of said members; said sleeve extending intosaid slots in engagement with said members; said releasable connectingmeans comprising segments on said mandrel engaging said body to transmitdownward thrust from said mandrel to said body and also comprising asplit ring on said mandrel engaging said body whereby the weight of saidbody and casing section therebelow are supported by said mandrel; saidsleeve engaging said segments to retain said segments in engagement withsaid body, said sleeve being released from said segments upon downwardmovement in said mandrel to permit disengagement of said segments fromsaid body, a lock sleeve in said body positioned for engagement by saidsplit ring and shifted downwardly in said body behind said members inresponse to downward movement of said mandrel and ring in said body tolock said members laterally outwardly, said split ring being expandablefrom said mandrel upon downward movement of said lock sleeve to releasesaid mandrel from said body and permit its movement longitudinallywithin and from said body; packing means on said mandrel for slidablysealing with the casing section following release of said mandrel fromsaid body and downward movement of said mandrel within the casingsection; said sleeve having one or more ports closed by said mandrelwhen said sleeve is in an upper position in said mandrel, said one ormore ports being opened when said sleeve has been shifted downwardly insaid mandrel.

35. A method of supporting a casing section in a well bore and carryingsupporting members on its upper portion, comprising lowering the casingsection in the well bore to a desired setting point, forming asupporting shoulder in the formation wall of the well bore at the upperportion of the casing section, and resting the supporting members on thesupporting shoulder to support the weight of the casing section.

23 53 um mm s'm'rms 1.A'l1.-31\'1 owner;

* CER'LIFlCA'lE OF CORRECTION Patent No. 3 ,570,603 Dated March 16 1971Imm t ARCHER w. KAMMERER, JR. ET AL It. is certified that error appearsin the above-identified patent and that said Letters Patent are herebycorrected as ehox-m below:

Column 7, lines 19 and 20, eahcel "resting thsupporting shoulderv in theformation wall of the well bore".

' Column 8, line 42, "slida-bl y" should read --slidab1e--.

Column 10, line 22, "aea" should read -seat--.

Signed and sealed this 28th de y of March 1 972.

(SEAL) Attest: c

EDWARD M.FLETCHER, JR. .ROBERT GOTTSCHALK A Attesting OfficerCommissioner of Patents

1. A method of supporting a casing section in a well bore and carryinginitially retracted supporting members, comprising lowering the casingsection in the well bore to a desired setting point, forming asupporting formation shoulder in the formation wall of the well bore,expanding the supporting members after lowering the casing section tothe desired setting point, and resting the supporting members on thesupporting formation shoulder to support the weight of the casingsection.
 2. A method of supporting a casing section in a well bore andcarrying supporting members, comprising lowering the casing section inthe well bore to a desired setting point, forming a supporting shoulderin the formation wall of the well bore, and resting the supportingmembers on the supporting shoulder; wherein the supporting members arelaterally expandable, forming the supporting shoulder by rotating atleast a portion of said casing section while laterally expanding thesupporting members to cause the supporting members to cut into theformation wall.
 3. A method as defined in claim 2; a hydraulic forcebeing imposed on the supporting members while said portion of the casingsection is being rotated to laterally expand the supporting members tocause the supporting members to cut into the formation wall and producethe supporting shoulder on which the supporting members rest.
 4. Amethod of supporting a casing section in a well bore and carryingsupporting members, comprising lowering the casing section in the wellbore to a desired setting point, forming a supporting shoulder in theformation wall of the well bore, and resting the supporting members onthe supporting shoulder; the casing section comprising an upperrotatable portion swivelly connected to a lower casing portion, thesupporting members being laterally expandable and carried by the upperrotatable portion, forming the supporting shoulder by rotating the upperrotatable portion and cutters by laterally expanding the supportingmembers to cause the supporting members to cut into the formation wall.5. A method of supporting and cementing a casing section in a well bore,the casing section carrying supporting members, comprising releasablyconnecting the casing section to a running tool and lowering the casingsection and running tool in the well bore on a tubular string to adesired setting point, forming a supporting shoulder in the formationwall of the well bore, resting the sUpporting shoulder in the formationwall of the well bore, resting the supporting members on the supportingshoulder, cementing the casing section in the well bore while thesupporting members rest on the shoulder, and releasing the running toolfrom the casing section for withdrawal of the running tool from the wellbore. 6 A method as defined in claim 5; wherein the running tool isreleased from the casing section prior to cementing the casing sectionin the well bore, lowering the running tool in the casing section to thelower portion of the casing section, then pumping cementitious materialthrough the tubular string and running tool into the casing section fordischarge from the casing section and upward flow around the casingsection.
 7. A method as defined in claim 5; wherein the supportingmembers are laterally expandable, forming the supporting shoulder byrotating the tubular string, running tool, and at least a portion ofsaid casing section while laterally expanding the supporting members tocause the supporting members to cut into the formation wall and producethe supporting shoulder on which the supporting members rest.
 8. Amethod as defined in claim 5; the casing section comprising an upperrotatable portion swivelly connected to a lower casing portion, thesupporting members being laterally expandable and carried by the upperrotatable portion, the running tool being releasably connected to theupper rotatable portion, forming the supporting shoulder by rotating thetubular string, running tool, upper rotatable portion, and supportingmembers carried thereby while exerting a hydraulically imposed force onthe supporting members to laterally expand the supporting members tocause the supporting members to cut into the formation wall and producethe supporting shoulder on which the supporting members rest.
 9. Amethod as defined in claim 5; the casing section comprising an upperrotatable portion swivelly connected to a lower casing portion, thesupporting members being laterally expandable and carried by the upperrotatable portion, the running tool being releasably connected to theupper rotatable portion, forming the supporting shoulder by rotating thetubular string, running tool, upper rotatable portion, and supportingmembers carried thereby while exerting a hydraulically imposed force onthe supporting members to laterally expand the supporting members tocause the supporting members to cut into the formation wall and producethe supporting shoulder on which the supporting members rest, therunning tool being released from the upper rotatable portion prior tocementing the casing section in the well bore, lowering the running toolin the casing section to the lower portion of the casing section, thenpumping cementitious material through the tubular string and runningtool into the casing section for discharge from the casing section andupward flow around the casing section.
 10. In apparatus for supporting acasing section in a well bore: a body adapted to form part of the casingsection; laterally expandable supporting members carried by the body;and means shiftable longitudinally of said body for expanding saidmembers laterally outwardly to penetrate said members into the formationwall of the well bore or to rest said members on a formation shoulder,whereby said members support the weight of said body in the casingsection from the formation wall or formation shoulder.
 11. In apparatusas defined in claim 10; and means for locking said members in theiroutwardly expanded position.
 12. In apparatus for supporting a casingsection in a well bore: a body adapted to form part of the casingsection; laterally expandable supporting members carried by the body;and means for expanding said members laterally outwardly to penetratesaid members into the formation wall of the well bore or to rest saidmembers on a formation shoulder, whereby said members support the weightof said body in the casing section from the formation wall oR formationshoulder; said body having swivel means for connecting said body to theportion of the casing section therebelow.
 13. In apparatus forsupporting a casing section in a well bore: a body adapted to form partof the casing section; laterally expandable supporting members carriedby the body; and means for expanding said members laterally outwardly topenetrate said members into the formation wall of the well bore or torest said members on a formation shoulder, whereby said members supportthe weight of said body in the casing section form the formation wall orformation shoulder; a running tool adapted to be secured to a runningstring and releasably connected to said body for lowering the body andremainder of the casing section in the well bore; and means drivablyconnecting said running tool to said supporting members whereby rotationof said running tool rotates said supporting members while they arebeing expanded laterally outwardly to produce the formation shoulder onwhich said supporting members can rest.
 14. In apparatus as defined inclaim 13; said body having swivel means for connecting said body to theportion of the casing section therebelow.
 15. In apparatus as defined inclaim 13; said expanding means comprising a member slidable downwardlyin said running tool in engagement with said supporting members toexpand said members laterally outwardly.
 16. In apparatus as defined inclaim 13; said expanding means comprising a fluid-actuated memberslidably longitudinally in said running tool and movable downwardly byfluid pressure in the running string in engagement with said supportingmembers to expand said members laterally outwardly.
 17. In apparatus asdefined in claim 13; said drivable connected means including slots insaid running tool into which said supporting members extend when inretracted position and during their lateral outward expansion.
 18. Inapparatus as defined in claim 13; and means for transmitting downwardlydirected thrust from said running tool to said body.
 19. In apparatus asdefined in claim 13; means for transmitting downwardly directed thrustfrom said running tool to said body; and means for releasing said thrusttransmitting means from its transmitting relation, permitting downwardmovement of said running tool in said body.
 20. In apparatus as definedin claim 13; means for transmitting downwardly directed thrust from saidrunning tool to said body; means for releasing said thrust transmittingmeans from its transmitting relation, permitting downward movement ofsaid running tool in said body; and lock means shiftable downwardly bysaid running tool within said body to a position behind said expandedsupporting members to lock said members in their expanded condition. 21.In apparatus for supporting a casing section in a well bore: a bodyconnectable to the casing section to form a part thereof; laterallyexpandable supporting members carried by said body; a mandrel withinsaid body and connectable to a tubular running string; means fortransmitting rotary motion of said mandrel to said members; an expanderslidable downwardly in said mandrel and engageable with said members toexpand said members laterally outwardly against the formation to producea shoulder in the formation during rotation of said mandrel and members;and means releasably connecting said mandrel to said body wherebyrelease of said connecting means permits said mandrel to movelongitudinally in said body to a position longitudinally removedtherefrom.
 22. In apparatus as defined in claim 21; said motiontransmitting means comprising slots in said mandrel receiving saidmembers when said members are in retracted position on said body andduring lateral expansion of said members.
 23. In apparatus as defined inclaim 21; said motion transmitting means comprising slots in saidmandrel receiving said members when said members are in retractedposition on said body and during lateral expansion of said members; saidExpander comprising means extending into said slots for engagement withsaid members.
 24. 24. In apparatus as defined in claim 21; said expandercomprising a sleeve having a seat, and a trip member movable through thetubular string into engagement with the seat to enable pressure to bebuilt up in the tubular string to fluidly shift said sleeve downwardlyin said mandrel in engagement with said members to expand said members.25. In apparatus as defined in claim 21; said expander comprising asleeve having a seat, and a trip member movable through the tubularstring into engagement with the seat to enable pressure to be built upin the tubular string to fluidly shift said sleeve downwardly in saidmandrel in engagement with said members to expand said members; saidsleeve having one or more ports closed by said mandrel when said sleeveis in an upper position in said mandrel, said one or more ports beingopened when said sleeve has been shifted downwardly in said mandrel. 26.In apparatus as defined in claim 21; said expander comprising a sleevehaving a seat, and a trip member movable through the tubular string intoengagement with the seat to enable pressure to be built up in thetubular string to fluidly shift said sleeve downwardly in said mandrelin engagement with said members to expand said members; said motiontransmitting means comprising slots in said mandrel receiving saidmembers when said members are in retracted position on said body andduring lateral expansion of said members; said sleeve extending intosaid slots in engagement with said members.
 27. In apparatus as definedin claim 21; said expander comprising a sleeve having a seat, and a tripmember movable through the tubular string into engagement with the seatto enable pressure to be built up in the tubular string to fluidly shiftsaid sleeve downwardly in said mandrel in engagement with said membersto expand said members; said motion transmitting means comprising slotsin said mandrel receiving said members when said members are inretracted position on said body and during lateral expansion of saidmembers; said sleeve extending into said slots in engagement with saidmembers; said sleeve having one or more ports closed by said mandrelwhen said sleeve is in an upper position in said mandrel, said one ormore ports being opened when said sleeve has been shifted downwardly insaid mandrel.
 28. In apparatus as defined in claim 21; and packing meanson said mandrel for slidably sealing with the casing section followingrelease of said mandrel from said body and downward movement of saidmandrel within the casing section.
 29. In apparatus as defined in claim21; said releasable connecting means comprising segments on said mandrelengaging said body to transmit downward thrust from said mandrel to saidbody and also comprising a split ring on said mandrel engaging said bodywhereby the weight of said body and casing section therebelow aresupported by said mandrel, and means for releasing said segments andsplit ring to release said mandrel from said body and permit movement ofsaid mandrel longitudinally within and from said body.
 30. In apparatusas defined in claim 21; and lock means shiftable behind said members toretain said members in expanded condition.
 31. In apparatus as definedin claim 21; said expander comprising a sleeve having a seat, and a tripmember movable through the tubular string into engagement with the seatto enable pressure to be built up in the tubular string to fluidly shiftsaid sleeve downwardly in said mandrel in engagement with said membersto expand said members; said motion transmitting means comprising slotsin said mandrel receiving said members when said members are inretracted position on said body and during lateral expansion of saidmembers; said sleeve extending into said slots in engagement with saidmembers; said releasable connecting means comprising segments on saidmandrel engaging said body to transmit downward thrust from said mandRelto said body and also comprising a split ring on said mandrel engagingsaid body whereby the weight of said body and casing section therebeloware supported by said mandrel, and means for releasing said segments andsplit ring to release said mandrel from said body and permit movement ofsaid mandrel longitudinally within and from said body.
 32. In apparatusas defined in claim 21; said expander comprising a sleeve having a seat,and a trip member movable through the tubular string into engagementwith the sea to enable pressure to be built up in the tubular string tofluidly shift said sleeve downwardly in said mandrel in engagement withsaid members to expand said members; said motion transmitting meanscomprising slots in said mandrel receiving said members when saidmembers are in retracted position on said body and during lateralexpansion of said members; said sleeve extending into said slots inengagement with said members; said releasable connecting meanscomprising segments on said mandrel engaging said body to transmitdownward thrust from said mandrel to said body and also comprising asplit ring on said mandrel engaging said body whereby the weight of saidbody and casing section therebelow are supported by said mandrel; saidsleeve engaging said segments to retain said segments in engagement withsaid body, said sleeve being released from said segments upon downwardmovement in said mandrel to permit disengagement of said segments fromsaid body, a lock sleeve in said body positioned for engagement by saidsplit ring and shifted downwardly in said body behind said members inresponse to downward movement of said mandrel and ring in said body tolock said members laterally outwardly, said split ring being expandablefrom said mandrel upon downward movement of said lock sleeve to releasesaid mandrel from said body and permit its movement longitudinallywithin and from said body.
 33. In apparatus as defined in claim 21; saidexpander comprising a sleeve having a seat, and a trip member movablethrough the tubular string into engagement with the seat to enablepressure to be built up in the tubular string to fluidly shift saidsleeve downwardly in said mandrel in engagement with said members toexpand said members; said motion transmitting means comprising slots insaid mandrel receiving said members when said members are in retractedposition on said body and during lateral expansion of said members; saidsleeve extending into said slots in engagement with said members; saidreleasable connecting means comprising segments on said mandrel engagingsaid body to transmit downward thrust from said mandrel to said body andalso comprising a split ring on said mandrel engaging said body wherebythe weight of said body and casing section therebelow are supported bysaid mandrel; said sleeve engaging said segments to retain said segmentsin engagement with said body, said sleeve being released from saidsegments upon downward movement in said mandrel to permit disengagementof said segments from said body, a lock sleeve in said body positionedfor engagement by said split ring and shifted downwardly in said bodybehind said members in response to downward movement of said mandrel andring in said body to lock said members laterally outwardly, said splitring being expandable from said mandrel upon downward movement of saidlock sleeve to release said mandrel from said body and permit itsmovement longitudinally within and from said body; and packing means onsaid mandrel for slidably sealing with the casing section followingrelease of said mandrel from said body and downward movement of saidmandrel within the casing section.
 34. In apparatus as defined in claim21; said expander comprising a sleeve having a seat, and a trip membermovable through the tubular string into engagement with the seat toenable pressure to be built up in the tubular string to fluidly shiftsaid sleeve downwardly in said mandrel in engagement with said membersto expand said memberS; said motion transmitting means comprising slotsin said mandrel receiving said members when said members are inretracted position on said body and during lateral expansion of saidmembers; said sleeve extending into said slots in engagement with saidmembers; said releasable connecting means comprising segments on saidmandrel engaging said body to transmit downward thrust from said mandrelto said body and also comprising a split ring on said mandrel engagingsaid body whereby the weight of said body and casing section therebeloware supported by said mandrel; said sleeve engaging said segments toretain said segments in engagement with said body, said sleeve beingreleased from said segments upon downward movement in said mandrel topermit disengagement of said segments from said body, a lock sleeve insaid body positioned for engagement by said split ring and shifteddownwardly in said body behind said members in response to downwardmovement of said mandrel and ring in said body to lock said memberslaterally outwardly, said split ring being expandable from said mandrelupon downward movement of said lock sleeve to release said mandrel fromsaid body and permit its movement longitudinally within and from saidbody; packing means on said mandrel for slidably sealing with the casingsection following release of said mandrel from said body and downwardmovement of said mandrel within the casing section; said sleeve havingone or more ports closed by said mandrel when said sleeve is in an upperposition in said mandrel, said one or more ports being opened when saidsleeve has been shifted downwardly in said mandrel.
 35. A method ofsupporting a casing section in a well bore and carrying supportingmembers on its upper portion, comprising lowering the casing section inthe well bore to a desired setting point, forming a supporting shoulderin the formation wall of the well bore at the upper portion of thecasing section, and resting the supporting members on the supportingshoulder to support the weight of the casing section.